Hydrocarbon determination in unconventional shale
An apparatus for identifying a fluid and locations of the fluid in a formation of shale having porous kerogen material and an inorganic matrix defining pores and micro-fractures includes: a carrier configured to be conveyed through a borehole penetrating the shale; a nuclear magnetic resonance (NMR) tool disposed at the carrier and configured to perform NMR measurements on the shale, the NMR measurements include a spectrum of transverse relaxation times; and a processor configured to receive NMR measurements on the shale performed by the NMR tool and to identify the fluid and locations of the fluid in the shale using the spectrum of transverse relaxation times.
1. An apparatus for identifying a fluid and locations of the fluid in a formation of shale comprising porous kerogen material and an inorganic matrix defining pores and micro-fractures, the apparatus comprising:
a carrier configured to be conveyed through a borehole penetrating the shale comprising porous kerogen material and an inorganic matrix defining pores and micro-fractures;
a nuclear magnetic resonance (NMR) tool disposed at the carrier and configured to perform NMR measurements on the shale comprising porous kerogen material and an inorganic matrix defining pores and micro-fractures, the NMR measurements comprising a spectrum of transverse relaxation times; and
a processor configured to receive NMR measurements on the shale comprising porous kerogen material and an inorganic matrix defining pores and micro-fractures performed by the NMR tool and to identify the fluid and locations of the fluid in the shale comprising porous kerogen material and an inorganic matrix defining pores and micro-fractures using the spectrum of transverse relaxation times.
2. The apparatus according to claim 1 , wherein the fluid is hydrocarbon material; and the hydrocarbon material is present in pores in the kerogen material in the shale.
3. The apparatus according to claim 2 , wherein a maximum peak of amplitude of the spectrum occurs at less than ten milliseconds transverse relaxation time.
4. The apparatus according to claim 3 , wherein the processor is further configured to estimate a percentage of the hydrocarbon material by total volume of the shale by integrating the spectrum over time.
5. The apparatus according to claim 1 , wherein the fluid is water disposed in pores of the inorganic matrix in the shale.
6. The apparatus according to claim 5 , wherein a maximum peak of amplitude of the spectrum occurs at less than 3.3 milliseconds transverse relaxation time.
7. The apparatus according to claim 6 , wherein the processor is further configured to estimate a percentage of the water by total volume of the shale by integrating the spectrum over time.
8. The apparatus according to claim 1 , wherein the fluid is liquid hydrocarbon material disposed in pores in the inorganic matrix in the shale.
9. The apparatus according to claim 8 , wherein a maximum peak of amplitude of the spectrum occurs at less than one second transverse relaxation time.
10. The apparatus according to claim 9 , wherein the processor is further configured to estimate a percentage of the hydrocarbon material by total volume of the shale by integrating the spectrum over time.
11. The apparatus according to claim 8 , wherein a maximum peak of amplitude of the spectrum is in a range of 20 to 200 milliseconds transverse relaxation time.
12. The apparatus according to claim 11 , further comprising estimating a percentage of the hydrocarbon material by total volume of the shale by integrating the spectrum over time.
13. The apparatus according to claim 1 , wherein the fluid is liquid hydrocarbon material disposed in the micro-fractures in the shale.
14. The apparatus according to claim 1 , wherein carrier comprises a wireline, a slickline, a drill string or coiled tubing.
15. The apparatus according to claim 1 , wherein pores of the porous kerogen material range in size from a nanometer to 100 nanometers.